EP3592714A1 - Procédé d'encapsulation d'agents de signalisation destinés à être utilisés en fond de trou - Google Patents

Procédé d'encapsulation d'agents de signalisation destinés à être utilisés en fond de trou

Info

Publication number
EP3592714A1
EP3592714A1 EP18713101.6A EP18713101A EP3592714A1 EP 3592714 A1 EP3592714 A1 EP 3592714A1 EP 18713101 A EP18713101 A EP 18713101A EP 3592714 A1 EP3592714 A1 EP 3592714A1
Authority
EP
European Patent Office
Prior art keywords
capsules
signaling agent
wellbore
cement
fluid
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Withdrawn
Application number
EP18713101.6A
Other languages
German (de)
English (en)
Inventor
Elizabeth Q. Contreras
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Saudi Arabian Oil Co
Original Assignee
Saudi Arabian Oil Co
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Saudi Arabian Oil Co filed Critical Saudi Arabian Oil Co
Publication of EP3592714A1 publication Critical patent/EP3592714A1/fr
Withdrawn legal-status Critical Current

Links

Classifications

    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
    • C09K8/46—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
    • C09K8/467—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J13/00—Colloid chemistry, e.g. the production of colloidal materials or their solutions, not otherwise provided for; Making microcapsules or microballoons
    • B01J13/02—Making microcapsules or microballoons
    • B01J13/06—Making microcapsules or microballoons by phase separation
    • B01J13/14—Polymerisation; cross-linking
    • B01J13/16—Interfacial polymerisation
    • C—CHEMISTRY; METALLURGY
    • C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
    • C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
    • C04B20/00—Use of materials as fillers for mortars, concrete or artificial stone according to more than one of groups C04B14/00 - C04B18/00 and characterised by shape or grain distribution; Treatment of materials according to more than one of the groups C04B14/00 - C04B18/00 specially adapted to enhance their filling properties in mortars, concrete or artificial stone; Expanding or defibrillating materials
    • C04B20/10—Coating or impregnating
    • C04B20/1018—Coating or impregnating with organic materials
    • C04B20/1029—Macromolecular compounds
    • C04B20/1033—Macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
    • C—CHEMISTRY; METALLURGY
    • C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
    • C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
    • C04B24/00—Use of organic materials as active ingredients for mortars, concrete or artificial stone, e.g. plasticisers
    • C04B24/24—Macromolecular compounds
    • C—CHEMISTRY; METALLURGY
    • C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
    • C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
    • C04B28/00—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
    • C04B28/02—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/13—Methods or devices for cementing, for plugging holes, crevices or the like
    • E21B33/14—Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B47/00—Survey of boreholes or wells
    • E21B47/005—Monitoring or checking of cementation quality or level
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
    • G01N33/38—Concrete; Lime; Mortar; Gypsum; Bricks; Ceramics; Glass
    • G01N33/383—Concrete or cement
    • C—CHEMISTRY; METALLURGY
    • C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
    • C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
    • C04B2103/00—Function or property of ingredients for mortars, concrete or artificial stone
    • C04B2103/0045—Polymers chosen for their physico-chemical characteristics
    • C04B2103/0058—Core-shell polymers
    • C—CHEMISTRY; METALLURGY
    • C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
    • C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
    • C04B2103/00—Function or property of ingredients for mortars, concrete or artificial stone
    • C04B2103/0045—Polymers chosen for their physico-chemical characteristics
    • C04B2103/0062—Cross-linked polymers
    • C—CHEMISTRY; METALLURGY
    • C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
    • C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
    • C04B2103/00—Function or property of ingredients for mortars, concrete or artificial stone
    • C04B2103/54—Pigments; Dyes
    • C—CHEMISTRY; METALLURGY
    • C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
    • C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
    • C04B2111/00—Mortars, concrete or artificial stone or mixtures to prepare them, characterised by specific function, property or use
    • C04B2111/80—Optical properties, e.g. transparency or reflexibility
    • C—CHEMISTRY; METALLURGY
    • C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
    • C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
    • C04B2111/00—Mortars, concrete or artificial stone or mixtures to prepare them, characterised by specific function, property or use
    • C04B2111/80—Optical properties, e.g. transparency or reflexibility
    • C04B2111/807—Luminescent or fluorescent materials

Definitions

  • the present disclosure relates to encapsulating a signaling agent for use downhole, and monitoring releases of the signaling agent. More specifically, the present disclosure relates to forming a membrane that encapsulates the signaling agent and that releases the signaling agent under designated conditions.
  • Hydrocarbons that are produced from subterranean formations typically flow from the formation to surface via wellbores that are drilled from surface and intersect the formation, where the wellbores are often lined with tubular casing.
  • the casing is usually bonded to the inner surface of the wellbore with a cement that is injected into an annulus that is between the casing and wellbore.
  • the cement also isolates adjacent zones within the formation from one another. Without the cement isolating these adjacent zones, the different fluids could become mixed, which requires subsequent separation, or can reduce the hydrocarbon producing potential of the wellbore.
  • the cement also blocks hydrocarbon fluid flow in the annulus between the casing and the wellbore wall. Without the cement, or in instances when cement has failed, hydrocarbon from the formation is known to migrate to surface. Sensors are available for monitoring cement integrity; but are brittle and thus subject to fracture when exposed to vibration and high temperatures downhole. Acoustic interrogation in the wellbore is another currently known technique for assessing cement quality, where a downhole tool is deployed within the casing which emits or induces sonic waves within the cement. Reflected waves are formed when the waves reach interfaces in the cement, and which are monitored and analyzed for cement evaluation. Acoustic monitoring though is time consuming and is performed when the well is off-line and not producing.
  • the capsules are optionally disposed in cement in the wellbore.
  • the method optionally includes monitoring the concentration of the signaling agent that releases from the capsules.
  • the signaling agent is a first signaling agent
  • the method alternatively further includes forming capsules having a second signaling agent and disposing the capsules having the second signaling agent at a designated depth in the wellbore that is different from a depth where capsules having the first signaling agent are disposed in the wellbore.
  • a characteristic of the cement is identifiable based on the step of monitoring the signaling agent.
  • Examples materials of the signaling agent include a dye, a fluorophore, an isotope, and combinations thereof.
  • the first and second reagents are alternatively compounds having a reactive functional group, and include one or more of monomers with tri-functional acid chlorides and monomers with di-functional amino groups.
  • the method further optionally includes encapsulating a sealing reagent for sealing cement.
  • Example characteristics of the polymer layers include permeability and yield strength.
  • the polymer layers are formulated to fail at one of a designated pressure, a designated temperature, or a designated temperature and designated pressure.
  • the method further includes controlling a release rate of the signaling agent from the polymer layers by adjusting one or more of, a viscosity of the first fluid, a permeability of the polymer layers, a size of the reagents, and a charge of the reagents.
  • Another example method of wellbore operations includes combining first and second solutions that each have a reactive monomer and a fluid that is immiscible with a fluid in the other solution, and at least one of the first or second solutions having a signaling agent, forming an emulsion with the first and second solutions that includes a continuous phase, and amounts of a dispersed phase containing the signaling agent and distributed within the continuous phase, forming polymeric layers around the amounts of the dispersed phase by reacting the monomers that define capsules containing the signaling agent, adjusting a concentration of a one of the reactive monomers to adjust a characteristic of polymer layers, disposing the capsules in cement that lines a wellbore, and evaluating a condition of the cement by sensing signaling agent that has escaped from the capsules in the cement.
  • the step of monitoring in this example includes using colorimetric spectroscopy, infrared spectroscopy, mass spectroscopy, visual inspection, a radiation detector, and combinations thereof.
  • Example emulsions include a water in oil emulsion, an oil in water emulsion, an oil in oil emulsion, and a water in water emulsion.
  • the reactive monomers optionally include compounds having multi-functional reactive groups.
  • Embodiments of the fluids include water, chloroform-cyclohexane, ethanol, and combinations thereof.
  • the signaling agent include colored dyes, fluorophore, isotopes, fluorescent dyes, fluorescein, and combinations thereof.
  • a further example method of wellbore operations includes using an interfacial polymerization technique of combining a monomer with a cross-linking monomer to form capsules that are made up of a signaling agent disposed within a polymer layer, adjusting an amount of the cross-linking monomer to control a characteristic of the polymer layer, disposing the capsules in a wellbore, and assessing a characteristic of the wellbore based on sensing the signaling agent escaping the capsules.
  • the capsules are disposed in wellbore cement.
  • One example characteristic of the wellbore is integrity of cement that lines the wellbore.
  • Figure 1 is a side partial sectional view of an example of a wellbore with casing and cement, where capsules having a signaling agent are disposed in the cement.
  • Figures 2 and 3 are schematic examples of forming the capsules of Figure 1.
  • Figure 4 is a graph having example plots representing light absorbance versus wavelength of capsules with membranes formed to have different characteristics.
  • Figure 5 is a graph with examples of absorbance over time of material being sensed that was released from the capsules of Figure 1.
  • FIG. 1 Illustrated in a side partial sectional view in Figure 1 is an example of monitoring signaling agents released from within a wellbore 10, where the wellbore 10 intersects a subterranean formation 12.
  • a wellhead assembly 14 shown mounted over an opening of the wellbore 10, and which provides pressure control of the wellbore 10.
  • wellhead assembly 14 includes a wellhead housing 16 which mounts on surface 18.
  • a production tree 20 is affixed to wellhead housing 16 for selectively distributing hydrocarbons produced from formation 12.
  • Production tubing 22 is inserted within wellbore 10, and conveys hydrocarbons to wellhead assembly 12 from the wellbore 10 produced from formation 12.
  • a conductor pipe 24 depends from a lower end of housing 16 into wellbore 10 and intersects the opening of wellbore 10.
  • Casing 26 is shown lining the wellbore 10, and which extends in the wellbore 10 past a terminal end of conductor pipe 24.
  • Casing 26 is spaced radially inward from the sidewalls of wellbore 10 so that an annulus 28 is formed between the outer surface of casing 26 and sidewalls of wellbore 10.
  • cement 30 fills a portion of annulus 28 and does not extend to the surface 18.
  • An annular space 31 is defined within annulus 28 between surface 18 and the upper surface of cement 30.
  • Capsules 32 which in an example contain one or more signaling agents, are shown scattered within cement 30.
  • capsules 32 collapse or otherwise fracture when subjected to a designated pressure or temperature and release the signaling agents.
  • signaling agents permeate from within capsules 32. Included in the present description are example methods of forming capsules 32 to collapse or fracture under designated conditions; also available are example methods of forming capsules 32 that release signaling agents through osmosis. Examples of signaling agents include a substance detectable upon irradiation of electromagnetic energy, such as but not limited to a spectrometer, a fluoroscope, ultraviolet light and the like.
  • Example components of a signaling agent include, a solubilized oilfield chemical reagent, a dye, a colorimetric dye, a water soluble dye, and a water soluble colorimetric dye, a fluorophore, an isotope, and combinations thereof.
  • a sensor 34 is shown within annular space 31, and which can sense the presence of signaling agents released from the capsules 32.
  • sensor 36 is shown coupled with or disposed within wellhead assembly 12. Each of the sensors 34, 36 are depicted in communication with a controller 38 via respective communication means 40, 42.
  • Example communication means 40, 42 include a hard-wired system, fiber optics, a wireless system, or combinations thereof.
  • controller 38 receives data from sensors 34, 36 and detects or estimates the presence of a signaling agent sensed by sensors 34, 36.
  • controller 38 in conjunction with one or more of sensors 34, 36, identifies a concentration, mass, or volume of the signaling agent(s).
  • Figure 2 shows in schematic form one example of a step of forming capsules 32 of Figure 1.
  • a first fluid 44 is in a first container 46; and a second fluid 48 is shown disposed within a second container 50.
  • the first and second fluids 44, 48 are immiscible with respect to one another; so that when first and second fluids 44, 48 are combined in a third container 52, an emulsion 54 is formed having a dispersed phase and a continuous phase.
  • amounts of the second fluid 48 are shown distributed throughout the first fluid 44 in container 52.
  • the first fluid 44 makes up a continuous phase.
  • the second fluid 48 makes up a dispersed phase.
  • second fluid 48 includes a signaling agent.
  • vesicles 56 are formed in the emulsion 54 which include or contain primarily the contents of the second fluid 48, and which is dispersed within first fluid 44. Examples exist where the emulsion 54 is a water and oil emulsion, an oil and water emulsion, an oil and oil emulsion, a water and water emulsion, and combinations thereof.
  • the first and second fluids 44, 48 are water or oil, and where monomer reagents are dispersed into each of the fluids 44, 48.
  • the fluids 44, 48 are made up of a combination of solvents and reagents.
  • the first fluid 44 contains a polar solvent
  • the second fluid 48 contains a non-polar solvent
  • first fluid 44 contains a non- polar solvent
  • the second fluid 48 contains a polar solvent.
  • the polar solvent includes water and the non-polar solvent includes a hydrocarbon substance such as an oil, chloroform, cyclohexane, a mix of chloroform and cyclohexane, and including combinations.
  • the signaling agent is included within the second fluid 48.
  • FIG. 3 Shown in a side sectional view in Figure 3 is a schematic example of capsules 32 forming within the container 52, where polymer membranes 58 define an outer layer of the capsules 32, and in which the capsules 32 have an amount of second fluid 48 captured within the polymer membranes 58.
  • each of the first and second fluids 44, 48 contain separate reagents that when combined form the polymer membrane 58, and which encapsulates the vesicles 56 of Figure 2.
  • the irregularly shaped vesicles 56 of Figure 2 become spherically shaped capsules 32 as shown in Figure 3.
  • Embodiments exist where diameters of the capsules 32 range in magnitude from about 10 microns to about 50 microns.
  • Examples of the different reagents that may be included in the first and second fluids 44, 48 include monomers with multiple functional reactive groups, such as acid chlorides that react with monomers having di-functional amino groups that form amide bonds.
  • the monomers include aromatic compounds having multi-functional reactive groups.
  • the multifunctional monomers form polyamide and polyaramide membranes that form a polyamide shell making up the polymer membrane 58.
  • Shown in Table 1 are example reactions for forming the polymer membrane 58.
  • Reference numerals are assigned to the chemical compounds provided in Table 1 and where the names of the chemicals with the assigned reference numerals are: (1) 1,3,5- benzenetricarboxylic acid chloride; (2) sebacoyl chloride; (3) ethylenediamine; (4) 1,4- diaminobenzene; (5) 1,3-diaminobenzene; (6) 1,6-diaminohexane; (7) poly(ethylene trimesoylamide); (8) poly-(para-phenylene trimesoylamide); (9) poly-(meta-phenylene trimesoylamide); (10) poly(hexamethylene trimesoylamide); and (11) poly(hexamethylene- co- sebacoyl trimesoylamide).
  • the reactive monomers are classified as Monomer A, Monomer B, and Co-monomer A.
  • Monomer A is depicted as 1,3,5-benzenetricarboxylic acid chloride, but can be any compound having multi-functional reactive groups, and being the range of Cs - Ci 2 or more.
  • Monomer A can be aromatic, cyclic, or linear.
  • Examples of Monomer B provided in Table 1 are compounds with di-functional amide groups, where the compounds include aromatic and linear organic compounds.
  • Monomer B includes cyclic organic compounds with multi-functional amide or amine groups. Example compounds making up Monomer B range from C2 - Cs or more.
  • a Co-monomer A is used in conjunction with Monomer A, and which is shown in Table 1 as sebacoyl chloride.
  • Co-monomer A includes a cyclic or aromatic compound with multiple function reactive groups.
  • Monomer A and Monomer B are disposed in separate ones of the first and second fluids 44, 48 prior those fluids 44, 48 being combined.
  • Embodiments exist where Co- monomer A is included in the same fluid as Monomer A.
  • Example polymerization times range from about 8 hours, about 24 hours, and greater than 24 hours.
  • the compound having the tri-functional reactive acid chlorides is referred to as a cross-linker.
  • the cross-linker defines a reagent or compound having more functional reactive groups than another reagent or compound being reacted with the cross-linker to form a polymer. Not intending to be bound by theory, but it is believed that varying the concentrations of the cross-linker adjusts the permeability and strength of the polymer membrane 58.
  • the release rate of the signaling agent is controlled by: (1) changing the viscosity of the dispersed phase within the emulsion 54; (2) the permeability of the polymer membrane 58, (3) the size and charge of the reagents used to form the polymer membrane 58; or (4) selective combinations of these.
  • the size, shape, or both the size and shape of the vesicles 56 is controlled by altering a mixing speed used for combining the first and second fluids 44, 48 within the container 52. In an example, a laminar flow is generated during interfacial polymerization and hollow fibers (not shown) are formed.
  • additional materials are encapsulated within the polymer membrane 58, and which in an alternative include sealing reagents, such as polymer, salt, rubber, water or any other chemistries needed to self-seal fractured cement.
  • Additional additives within the polymer membrane 58 include cement additives, gas scrubbers, and anti- gas migration additives.
  • integrity of the cement 30 of Figure 1 is selectively monitored over the life of the well by formulating the polymer membrane 58 to collapse or otherwise rupture under a designated pressure or temperature.
  • the sensors 34, 36 sense signaling agents that have been released from capsules 32 that rupture in response to exposure to a designated pressure or temperature, an indication of conditions of the cement 30 is obtainable.
  • the capsules 32 rupture in response to a combination of a designated temperature and pressure.
  • sensing signaling agents with sensors 34, 36, that was released from ruptured capsules 32 disposed in the cement 30 is an indicator of possible failure of the cement 30.
  • a designated pressure occurs in the cement 30 from gas migrating into the cement 30 from the adjacent formation 12.
  • capsules 32 that burst or rupture at different ambient pressures or temperatures are disposed at different depths within the wellbore 10, so that specific conditions at designated depths are detectable.
  • capsules 32 disposed at different depths contain different signaling agents.
  • groups of capsules 32 with encapsulated colorimetric dye SAFC, were vacuum filtered and dried into a free flowing powder.
  • the dye in the capsules 32 permeated through the membranes 58 and tinted the water with the color of the dye.
  • Absorbance values for each sample of the tinted water were measured with a spectrometer. The measured absorbance values provided correlations to permeability of the membranes 58 of each group of capsules 32.
  • the polymer membranes 58 of each group of capsules 32 were formed having a different amount of a cross-linker. Not intending to be bound by theory, it is believed that the permeability of the membranes 58, and thus the measured absorbance values, were directly affected by the amount of cross-linker added during the process of forming the capsules 32.
  • FIG 4 shown is a graph 60 with an X-Y axis having an abscissa 62 and an ordinate 64.
  • Charted on graph 60 are a series of plots 66, 68, 70, 72 that graphically illustrate results of this example of illuminating different groups of capsules 32, and measuring an absorbance of that light for each group of capsules 32.
  • abscissa 62 represents the wavelength of a light being emitted into the tinted water, and corresponding light absorbance of the tinted water is presented along the ordinate 64.
  • the different plots 66, 68, 70, 72 each represent measured absorbance values over a range of wavelengths of illuminated light, of water tinted by the different groups of capsules 32 made from different amounts of a cross-linker. More specifically, plot 66 represents absorbance data obtained from 2 ml of water tinted by the addition of a group of capsules 32 whose corresponding polymer membranes 58 were formed with a cross-linker having a concentration of 23.1 millimolar.
  • Plot 68 represents the absorbance obtained from water tinted from 2 ml of water tinted by a group of capsules 32 where the cross-linker concentration was 46.2 millimolar
  • plot 70 the cross-linker concentration when forming the group of capsules 32 was 76.9 millimolar
  • plot 72 the cross-linker concentration when forming the group of capsules 32 was 153.8 millimolar.
  • the intensity of the absorbance (as illustrated by the values taken along the ordinate 64) increases with a decrease in the corresponding cross-linker concentration within the capsules 32.
  • the permeability of the polymer membrane 58 making up the individual capsules 32 decreases with an increase in the cross-linker concentration.
  • the release rate of signaling agent from the capsules 32 varies with permeability of the membranes 58 of the capsules 32. Because concentrations of cross- linkers added to form the membranes 58 affects the permeability of the membranes 58 (and thus the capsules 32), embodiments exist where a designated release rate is obtained with strategic control of cross-linker concentrations.
  • a release rate of the signaling agent from the polymer membranes 58 is controlled by adjusting one or more of, a viscosity of the fluids 44, 48, a permeability of the polymer membranes 58, a size of the reagents, and a charge of the reagents. It is within the capabilities of those skilled in the art to identify and/or add particular amounts of cross-linking constituents when forming the capsules 32, so that the polymer membranes 58 of the capsules 32 have a designated yield strength to yield, rupture, or burst under certain environmental conditions such as pressure, temperature, or a combination of both. It is further within the capabilities of those skilled in the art to identify and/or add particular amounts of cross-linking constituents when forming the capsules 32, so that the polymer membranes 58 of the capsules 32 have a designated permeability.
  • Embodiments of controlling permeability of membranes 58 include using different starting diamine monomers (hexadiamine vs. phenylenediamine, for example).
  • strength of a membrane 58 is obtained by allowing increased reaction time to polymerize to a greater molecular weight, which in one example is a minimum of six hours.
  • hexadiamene monomer is included when forming the capsules 32, which provides high permeability and high strength.
  • a designated permeability of a polymer membrane 58 with a capsule 32 depends on a size of molecules within the signaling agent.
  • the capsules 32 containing the signaling agent of a higher molecular weight would be formed with a polymer membrane 58 having a higher permeability (i.e. lower cross- linker concentration).
  • Figure 5 shows a graph 74 having an X - Y axis, and with an abscissa 76 and ordinate 78.
  • Represented in Figure 5 is a prophetic example of monitoring events downhole is illustrated where the signaling agent is detected spectroscopically to obtain values of absorbance; and values of measured absorbance over time are plotted. Values of time in Figure 5 are represented along the abscissa 76, and values of absorbance are represented by ordinate 78.
  • Data points 80 represent instances of dye being detected by one or more sensors 34, 36 ( Figure 1), where the dye had been released from the capsules 32 disposed in cement 30.
  • a triggered release shows a delay in detection. Over time, the release rate of the encapsulated signaling agent into solution is detected and increases until spent. The data illustrates a passive release.
  • Advantages of disclosed embodiments include a one -pot synthesis of forming the capsules 32.
  • Alternate embodiments provide an advantage of encapsulating different signal chemical additives, polymers, and dispersed solutions with a robust capsule 32 for embedment into cement 30.
  • Further advantages include that loading amounts of signaling agents in the hollow shells are optionally changed, polymer shell shields signaling agents from environment, shell is elastic, embodiments of polymer layers are heat resistant and useful in high temperature applications, cement properties are improved with release of optional additives in capsules, and pressure excursions that exceed a designated amount are detectable with the release of encapsulated signaling agents.
  • capsules 32 can remain intact within the cement 30 and not rupture.
  • the intact capsules 32 can optionally affect mechanical properties of the cement 30, such as by increasing or decreasing ductility, flexibility, tensile strength, or yield strength of the cement 30.

Landscapes

  • Chemical & Material Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Ceramic Engineering (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Organic Chemistry (AREA)
  • Materials Engineering (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Structural Engineering (AREA)
  • Physics & Mathematics (AREA)
  • Inorganic Chemistry (AREA)
  • Health & Medical Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Analytical Chemistry (AREA)
  • Medicinal Chemistry (AREA)
  • General Physics & Mathematics (AREA)
  • Food Science & Technology (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Fluid Mechanics (AREA)
  • Biochemistry (AREA)
  • General Health & Medical Sciences (AREA)
  • Environmental & Geological Engineering (AREA)
  • Immunology (AREA)
  • Pathology (AREA)
  • Dispersion Chemistry (AREA)
  • Quality & Reliability (AREA)
  • Geophysics (AREA)
  • Manufacturing Of Micro-Capsules (AREA)
  • Investigating Or Analysing Materials By The Use Of Chemical Reactions (AREA)

Abstract

L'invention concerne un procédé de surveillance des conditions dans un puits de forage (10) par placement de capsules (32) dotées d'un agent de signalisation en fond de trou, et surveillance de la présence de l'agent de signalisation libéré des capsules (32) qui s'échappent du puits de forage (10). Les capsules (32) sont formées par combinaison de liquides non miscibles, où l'un des liquides contient la substance de signalisation, et chacun des liquides contient un réactif. Une fois combinés, les liquides se séparent en une phase dispersée et une phase continue, la phase dispersée contenant l'agent de signalisation. Les réactifs réagissent aux interfaces entre les phases dispersée et continue et forment des couches polymères encapsulant l'agent de signalisation pour former les capsules (32). Une fois placées en fond de trou, comme dans le ciment de tubage (30), les membranes des capsules éclatent sous l'effet de la pression ou de la température pour libérer l'agent de signalisation. L'ajustement des concentrations relatives des réactifs permet de faire varier la résistance mécanique et la perméabilité des membranes.
EP18713101.6A 2017-03-07 2018-03-07 Procédé d'encapsulation d'agents de signalisation destinés à être utilisés en fond de trou Withdrawn EP3592714A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US201762468076P 2017-03-07 2017-03-07
PCT/US2018/021291 WO2018165256A1 (fr) 2017-03-07 2018-03-07 Procédé d'encapsulation d'agents de signalisation destinés à être utilisés en fond de trou

Publications (1)

Publication Number Publication Date
EP3592714A1 true EP3592714A1 (fr) 2020-01-15

Family

ID=61764149

Family Applications (1)

Application Number Title Priority Date Filing Date
EP18713101.6A Withdrawn EP3592714A1 (fr) 2017-03-07 2018-03-07 Procédé d'encapsulation d'agents de signalisation destinés à être utilisés en fond de trou

Country Status (5)

Country Link
US (2) US10370578B2 (fr)
EP (1) EP3592714A1 (fr)
CN (1) CN110382438B (fr)
CA (1) CA3054429C (fr)
WO (1) WO2018165256A1 (fr)

Families Citing this family (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2016025828A1 (fr) * 2014-08-15 2016-02-18 Baker Hughes Incorporated Procédés et systèmes pour surveiller une formation souterraine et une production de puits de forage
BR112018070887B1 (pt) 2016-04-15 2022-07-26 Total Sa Método para determinar uma janela de tempo na qual um teste de pressão de revestimento pode ser executado sem danificar uma bainha de cimento
WO2017178860A1 (fr) * 2016-04-15 2017-10-19 Total Sa Procédé de détermination de paramètre de plasticité de pâte de ciment hydratant
CA3054429C (fr) * 2017-03-07 2021-08-31 Saudi Arabian Oil Company Procede d'encapsulation d'agents de signalisation destines a etre utilises en fond de trou
CN112502684B (zh) * 2020-12-08 2022-12-23 中国石油天然气集团有限公司 油气储层改造工艺及造复杂裂缝的方法和自爆炸式支撑剂
CN118533726B (zh) * 2024-07-26 2024-09-20 中国石油大学(华东) 一种聚合物胶囊动态吸附滞留量测定方法

Family Cites Families (33)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3429827A (en) 1962-11-23 1969-02-25 Moore Business Forms Inc Method of encapsulation
EP0671549A1 (fr) * 1994-03-10 1995-09-13 Shell Internationale Researchmaatschappij B.V. Procédé de production d'un fluide contenu dans une formation géologique
WO1997021117A1 (fr) * 1995-12-05 1997-06-12 Lwt Instruments Inc. Structures de materiaux composites possedant une attenuation de signal reduite
US6444316B1 (en) 2000-05-05 2002-09-03 Halliburton Energy Services, Inc. Encapsulated chemicals for use in controlled time release applications and methods
US6854522B2 (en) * 2002-09-23 2005-02-15 Halliburton Energy Services, Inc. Annular isolators for expandable tubulars in wellbores
US20040171499A1 (en) 2003-01-24 2004-09-02 Halliburton Energy Services, Inc. Cement compositions with improved mechanical properties and methods of cementing in a subterranean formation
CN101123890B (zh) * 2004-10-04 2012-11-07 迈图专业化学股份有限公司 估测裂缝几何形状的方法，用于该方法的组合物和制品
US7712527B2 (en) 2007-04-02 2010-05-11 Halliburton Energy Services, Inc. Use of micro-electro-mechanical systems (MEMS) in well treatments
US9200500B2 (en) 2007-04-02 2015-12-01 Halliburton Energy Services, Inc. Use of sensors coated with elastomer for subterranean operations
US9822631B2 (en) 2007-04-02 2017-11-21 Halliburton Energy Services, Inc. Monitoring downhole parameters using MEMS
US9494032B2 (en) 2007-04-02 2016-11-15 Halliburton Energy Services, Inc. Methods and apparatus for evaluating downhole conditions with RFID MEMS sensors
US8047282B2 (en) * 2009-08-25 2011-11-01 Halliburton Energy Services Inc. Methods of sonically activating cement compositions
CN102791959B (zh) 2010-02-12 2016-08-31 旦·安杰列丝库 无源微容器及传感器
WO2013009895A1 (fr) 2011-07-12 2013-01-17 Lawrence Livermore National Security, Llc Traceurs encapsulés et produits chimiques pour interrogation et manipulation de réservoir
US20130126164A1 (en) * 2011-11-22 2013-05-23 Halliburton Energy Services, Inc. Releasing activators during wellbore operations
US9410076B2 (en) * 2012-10-25 2016-08-09 Halliburton Energy Services, Inc. Wellbore servicing methods and compositions comprising degradable polymers
RU2544355C2 (ru) * 2013-03-18 2015-03-20 Закрытое акционерное общество "ИМЭТСТРОЙ" (ЗАО "ИМЭТСТРОЙ") Способ производства наноцемента и наноцемент
WO2014189766A2 (fr) 2013-05-21 2014-11-27 Halliburton Energy Services, Inc. Bille de fracturation en mousse syntactique et ses procédés d'utilisation
US9856414B2 (en) * 2013-06-10 2018-01-02 Dober Chemical Corp. Compositions, systems and methods of making coated additive components
US20150034310A1 (en) 2013-08-01 2015-02-05 Ionic Research Technologies Llc Compounds, compositions and methods for enhancing oil recovery
AU2013399169B2 (en) 2013-08-27 2017-03-16 Halliburton Energy Services, Inc. Energetic cocrystals for treatment of a subterranean formation
US9416619B2 (en) * 2013-10-16 2016-08-16 Lawrence Livermore National Security, Llc Cementing a wellbore using cementing material encapsulated in a shell
WO2015126365A1 (fr) 2014-02-18 2015-08-27 Halliburton Energy Services, Inc. Procédés permettant d'obtenir des données à partir d'une formation souterraine
CN103979824B (zh) * 2014-04-28 2016-08-24 同济大学 原位聚合法制备用于水泥基材料自修复的微胶囊制备方法
US9751812B2 (en) 2014-05-30 2017-09-05 Elwha Llc Taggant for cement authentication
US10758458B2 (en) * 2014-09-25 2020-09-01 Premier Dental Products Company Bondable microcapsules and surface functionalized fillers
AU2014408261B2 (en) * 2014-10-07 2018-06-14 Halliburton Energy Services, Inc. Treatment of subterranean formations with self-healing resins
US20170247608A1 (en) 2014-10-30 2017-08-31 Halliburton Energy Services, Inc. Proppant of an electrically-conductive nano material
CN105254226A (zh) * 2015-10-01 2016-01-20 中国石油集团西部钻探工程有限公司 弹性水泥浆及其制备方法
US10526523B2 (en) * 2016-02-11 2020-01-07 Schlumberger Technology Corporation Release of expansion agents for well cementing
US10377940B2 (en) * 2016-09-20 2019-08-13 Saudi Arabian Oil Company Cement having cross-linked polymers
US10513905B2 (en) * 2017-03-07 2019-12-24 Saudi Arabian Oil Company Wellbore cement having spent polymer capsule shells
CA3054429C (fr) * 2017-03-07 2021-08-31 Saudi Arabian Oil Company Procede d'encapsulation d'agents de signalisation destines a etre utilises en fond de trou

Also Published As

Publication number Publication date
CN110382438A (zh) 2019-10-25
CN110382438B (zh) 2022-08-02
US10370578B2 (en) 2019-08-06
US10435613B2 (en) 2019-10-08
CA3054429A1 (fr) 2018-09-13
CA3054429C (fr) 2021-08-31
US20180362828A1 (en) 2018-12-20
US20180258337A1 (en) 2018-09-13
WO2018165256A1 (fr) 2018-09-13

Similar Documents

Publication Publication Date Title
CA3054429C (fr) Procede d'encapsulation d'agents de signalisation destines a etre utilises en fond de trou
US10513905B2 (en) Wellbore cement having spent polymer capsule shells
EP1277051B1 (fr) Systeme de controle d'un reservoir
US20010036667A1 (en) Reservoir monitoring
NO342683B1 (no) Fremgangsmåte for å bestemme konsentrasjon av sporstoff i fluider ved olje- og gassproduksjon
EP3121368B1 (fr) Methode de tracing dans un puits de forage de petrole
US20130269423A1 (en) Passive Micro-vessel and Sensor
US20020079098A1 (en) Method and apparatus for a tubing conveyed perforating guns fire identification system using enhanced marker material
EP3168595B1 (fr) Système et procédé d'échantillonnage dans un corps fluide
CA3036377A1 (fr) Ciment ayant des polymeres reticules
WO2014062920A1 (fr) Emballages passifs pour la libération d'agents chimiques dans des puits de forage
RU2569143C1 (ru) Способ определения дебитов воды, нефти, газа с использованием расходомерного устройства
AU2019232161A1 (en) Method for quantifying porous media by means of analytical particles and uses thereof
DK179404B1 (en) A System And A Method For Determining Inflow Distribution In An Openhole Completed Well
CN113841038A (zh) 使用三轴压力离心机设备测试石油物理性质
CN113811753A (zh) 使用三轴压力离心机设备测试石油物理性质
US10947438B2 (en) Method for monitoring cement using polymer-based capsules
RU2685601C1 (ru) Способ определения дебитов воды, нефти, газа
EP3740746A1 (fr) Micro-récipient passif et capteur
EP2953677B1 (fr) Microvaisseau passif et capteur de détermination de viscosité
Pairoys et al. Effect of the presence of interstitial brine on gas-oil capillary pressure

Legal Events

Date Code Title Description
STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: UNKNOWN

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE INTERNATIONAL PUBLICATION HAS BEEN MADE

PUAI Public reference made under article 153(3) epc to a published international application that has entered the european phase

Free format text: ORIGINAL CODE: 0009012

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: REQUEST FOR EXAMINATION WAS MADE

17P Request for examination filed

Effective date: 20190930

AK Designated contracting states

Kind code of ref document: A1

Designated state(s): AL AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HR HU IE IS IT LI LT LU LV MC MK MT NL NO PL PT RO RS SE SI SK SM TR

AX Request for extension of the european patent

Extension state: BA ME

DAV Request for validation of the european patent (deleted)
DAX Request for extension of the european patent (deleted)
STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: EXAMINATION IS IN PROGRESS

17Q First examination report despatched

Effective date: 20220530

STAA Information on the status of an ep patent application or granted ep patent

Free format text: STATUS: THE APPLICATION IS DEEMED TO BE WITHDRAWN

18D Application deemed to be withdrawn

Effective date: 20231003